ABB REF630 User manual

Type
User manual
Relion
®
630 series
Feeder Protection and Control
REF630
Product Guide
Contents
1. Description...........................................................3
2. Application...........................................................3
3. Preconfigurations.................................................5
4. Protection functions.............................................8
5. Control................................................................12
6. Fault location......................................................12
7. Measurement.....................................................12
8. Disturbance recorder..........................................12
9. Event log.............................................................13
10. Disturbance report............................................13
11. Circuit-breaker monitoring................................13
12. Trip-circuit supervision......................................13
13. Self-supervision.................................................14
14. Fuse failure supervision.....................................14
15. Current circuit supervision................................14
16. Access control...................................................14
17. Inputs and outputs............................................14
18. Communication.................................................15
19. Technical data...................................................16
20. Front panel user interface.................................61
21. Mounting methods............................................61
22. Selection and ordering data..............................63
23. Accessories.......................................................67
24. Tools..................................................................68
25. Supported ABB solutions..................................69
26. Terminal diagram...............................................70
27. References........................................................73
28. Functions, codes and symbols.........................73
29. Document revision history.................................76
Disclaimer
The information in this document is subject to change without notice and should not be construed as a commitment by ABB Oy. ABB Oy assumes
no responsibility for any errors that may appear in this document.
© Copyright 2009 ABB Oy.
All rights reserved.
Trademarks
ABB and Relion are registered trademarks of ABB Group. All other brand or product names mentioned in this document may be trademarks or
registered trademarks of their respective holders.
Feeder Protection and Control 1MRS756380 A
REF630
Product version: 1.0 Issued: 15.09.2009
2 ABB
1. Description
REF630 is a comprehensive feeder
management IED for protection, control,
measuring and supervision of utility and
industrial distribution substations. REF630 is
a member of ABB’s Relion
®
product family
and a part of its 630 protection and control
product series characterized by functional
scalability and flexible configurability.
REF630 also features necessary control
functions constituting an ideal solution for
feeder bay control.
The 630 series IEDs support the new IEC
61850 substation automation standard
including horizontal GOOSE communication
and the DNP3 communication protocol
offering seamless connectivity to station
automation and SCADA systems.
2. Application
REF630 provides main protection for
overhead lines and cable feeders of
distribution networks. The IED fits both
isolated neutral networks and networks with
resistance or impedance earthed neutral. Four
pre-defined configurations to match typical
feeder protection and control requirements
are available. The pre-defined configurations
can be used as such or easily adapted or
extended with freely selectable add-on
functions, by means of which the IED can be
fine-tuned to exactly satisfy the specific
requirements of your present application.
Feeder Protection and Control 1MRS756380 A
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Product version: 1.0 Issued: 15.09.2009
Revision: A
ABB 3
GUID-EBE462A5-7366-467A-BA18-583E75428EDB V1 EN
Figure 1. RET630 and REF630 IEDs applied for the incoming feeder and primary switchgear
in a double busbar arrangement. The RET630 with preconfiguration A is used for
protection and control of the power transformer, the REF630 with preconfiguration B
protects and controls the outgoing feeder and the REF630 with preconfiguration D is
used for the bus sectionalizer.
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3. Preconfigurations
The 630 series IEDs are offered with optional
factory-made application preconfigurations.
The preconfigurations contribute to faster
commissioning and less engineering of the
IED. The preconfigurations include default
functionality typically needed for a specific
application. Each preconfiguration is
adaptable using the Protection and Control
IED Manager PCM600. By adapting the
preconfiguration the IED can be configured
to suit the particular application.
The adaptation of the preconfiguration may
include adding or removing of protection,
control and other functions according to the
specific application, changing of the default
parameter settings, configuration of the
default alarms and event recorder settings
including the texts shown in the HMI,
configuration of the LEDs and function
buttons, and adaptation of the default single-
line diagram.
In addition, the adaptation of the
preconfiguration always includes
communication engineering to configure the
communication according to the functionality
of the IED. The communication engineering
is done using the communication
configuration function of PCM600.
If none of the offered preconfigurations fulfill
the needs of the intended area of application
the 630 series IEDs can also be ordered
without any preconfiguration. This option
enables full flexibility to configure the IED
from the ground up.
Table 1. REF630 preconfigurations
Description Preconfiguration
Preconfiguration A for open/closed ring feeder A
Preconfiguration B for radial overhead/mixed line feeder B
Preconfiguration C for ring/meshed feeder C
Preconfiguration D for bus sectionalizer D
Number of instances available N
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Table 2. Supported functions
Functionality A B C D N
Protection
Three-phase non-directional overcurrent, low stage 1 1 1 1 1
Three-phase non-directional overcurrent, high stage 2 2 2 2 2
Three-phase non-directional overcurrent, instantaneous stage 1 1 1 1 1
Three-phase directional overcurrent, low stage 2 - - - 2
Three-phase directional overcurrent, high stage 1 - - - 1
Non-directional earth fault, low stage - 1 - 1 1
Non-directional earth fault, high stage 1 1 1 1 1
Non-directional earth fault, instantaneous stage - 1 - 1 1
Directional earth fault, low stage 2 1 3 - 3
Directional earth fault, high stage 1 - 1 - 1
Transient/intermittent earth fault 1 - - - 1
Negative-sequence overcurrent 2 2 2 2 2
Three-phase thermal overload for feeder 1 1 1 - 1
Phase discontinuity 1 1 1 - 1
Three-phase current inrush detection 1 1 1 1 1
Three-phase overvoltage - - 3 - 3
Three-phase undervoltage - - 3 - 3
Positive-sequence overvoltage
1)
- - - -
2
Positive-sequence undervoltage
1)
- - - -
2
Negative-sequence overvoltage
1)
- - - -
2
Residual overvoltage - - 3 - 3
Frequency gradient - - - - 5
Overfrequency - - - - 5
Underfrequency - - - - 5
Load shedding - - - - 6
Fault locator
1)
- - - -
1
Circuit-breaker failure 1 1 1 1 2
Autoreclosing 1 1 1 - 2
Tripping logic 1 1 1 1 2
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Table 2. Supported functions, continued
Functionality A B C D N
Distance protection
1)
- - 1 -
1
Automatic switch-onto-fault logic - - 1 - 2
Protection related functions
Local accelerat. logic - - 1 - 1
Communication logic for residual OC - - 1 - 1
Scheme communic. logic - - 1 - 1
Current reversal and WEI logic - - 1 - 1
Current reversal and WEI logic for residual OC - - 1 - 1
Control
Bay control 1 1 1 1 1
Interlocking interface 4 4 4 1 10
Circuit-breaker/disconnector control 4 4 4 1 10
Circuit breaker 1 1 1 1 2
Disconnector 3 3 3 - 8
Local/remote switch interface - - - - 1
Synchrocheck
1)
- - - -
1
Supervision and monitoring
Circuit-breaker condition monitoring 1 1 1 1 2
Fuse failure supervision 1 1 1 - 2
Current-circuit supervision 1 1 1 - 2
Trip-circuit supervision 3 3 3 3 3
Station battery supervision - - - - 1
Energy monitoring - - - - 1
Generic measured values - - - - 3
Measured value limit supervision - - - - 9
Measurement
Three-phase current 1 1 1 1 1
Three-phase voltage, phase-to-earth 1 1 1 1 1
Three-phase voltage, phase-to-phase - - - - 1
Residual current 1 1 1 1 1
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Table 2. Supported functions, continued
Functionality A B C D N
Residual voltage 1 1 1 - 1
Power monitoring with P, Q, S, power factor, frequency 1 1 1 1 1
Sequence current 1 1 1 1 1
Sequence voltage 1 1 1 1 1
Metering
Pulse counter for energy metering - - - - 4
Disturbance recorder function
Analog channels 1-10 (samples) 1 1 1 1 1
Analog channel 11-20 (samples) - - - - 1
Analog channel 21-30 (samples) - - - - 1
Analog channel 31-40 (calc val) - - - - 1
Binary channels 1-16 1 1 1 1 1
Binary channels 17-32 1 1 1 1 1
Binary channels 33-48 1 1 1 1 1
Binary channels 49-64 1 - 1 - 1
1) Optional functions, to be specified at ordering
4. Protection functions
The IED offers selective short-circuit and
overcurrent protection including three-phase
non-directional overcurrent protection with
four independent stages, and three-phase
directional overcurrent protection with three
independent stages. In addition, the IED
includes three-phase current inrush detection
for blocking selected overcurrent protection
stages or temporarily increasing the setting
values. The included thermal overload
protection function uses thermal models of
overhead lines and cables. The negative-
sequence overcurrent protection, with two
independent stages, is used for phase-
unbalance protection. In addition, the IED
offers phase discontinuity protection.
Further, the IED features selective earth-fault
and cross country fault protection for isolated
neutral, and for resistance and/or impedance
earthed neutral systems including solidly
earthed neutral systems. The earth-fault
protection includes non-directional earth-fault
protection with three independent stages and
directional earth-fault protection with four
independent stages.
The included transient/intermittent earth-fault
protection is based on detection of earth-fault
transients related to continuous or
intermittent faults. Intermittent earth-fault is
special type of earth-fault encountered in
compensated networks with underground
cables. In solidly earthed or compensated
networks the transient earth-fault protection
function detects earth-faults with low fault
resistance. The residual overvoltage
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protection, with three independent stages, is
used for earth-fault protection of the
substation bus and the incoming feeder, and
for back-up protection of the outgoing feeders.
The IED offers distance protection including
both circular (mho) and quadrilateral (quad)
zone characteristics, three independent zones
with separate reach settings for phase-to-
phase and phase-to-earth measuring elements
and two zones for controlling auto-reclosing
of circuit breakers. Further, the IED offers
automatic switch onto fault logic with voltage
and current based detection options.
The IED offers voltage protection functions
including three-phase undervoltage and
overvoltage protection with three
independent stages each, both with phase-to-
phase or phase-to-earth measurement. The
IED offers overfrequency, underfrequency
and rate-of-change of frequency protection to
be used in load shedding and network
restoration applications.
In addition the IED offers three-pole multi-
shot autoreclose functions for overhead line
feeders.
The IED incorporates breaker failure
protection for circuit breaker re-tripping or
back-up tripping for the upstream breaker.
GUID-8D94ABFF-3F94-4C26-BDF5-2F4DD4B906FB V1 EN
Figure 2. Protection function overview of preconfiguration A
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GUID-4460293F-E493-4876-8B35-EA12DD21B7BD V1 EN
Figure 3. Protection function overview of preconfiguration B
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GUID-A0FC88A2-E407-4A57-86B8-8845CE7AD078 V1 EN
Figure 4. Protection function overview of preconfiguration C
GUID-CE8BEBCD-9D9B-4FE6-A9EF-AF4690339584 V1 EN
Figure 5. Protection function overview of preconfiguration D
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5. Control
The IED incorporates local and remote
control functions. The IED offers a number of
freely assignable binary inputs/outputs and
logic circuits for establishing bay control and
interlocking functions for circuit breakers and
motor operated switch-disconnectors. The
IED supports both single and double busbar
substation busbar layouts. The number of
controllable primary apparatuses depends on
the number of available inputs and outputs in
the selected configuration. Besides
conventional hardwired signaling also
GOOSE messaging according to IEC
61850-8-1 can be used for signal interchange
between IEDs to obtain required interlockings.
Further, the IED incorporates a synchro-
check function to ensure that the voltage,
phase angle and frequency on either side of
an open circuit breaker satisfy the conditions
for safe interconnection of two networks.
6. Fault location
REF630 features an impedance-measuring
fault location function suitable for locating
short-circuits in radial distribution systems.
Earth faults can be located in effectively and
low-resistance earthed networks. Under
circumstances where the fault current
magnitude is at least of the same order of
magnitude or higher than the load current,
earth faults can also be located in isolated
neutral distribution networks. The fault
location function identifies the type of the
fault and then calculates the distance to the
fault point. An estimate of the fault resistance
value is also calculated. The estimate
provides information about the possible fault
cause and the accuracy of the estimated
distance to the fault point.
7. Measurement
The IED continuously measures the phase
currents, positive and negative sequence
currents and the residual current. The IED
also measures phase-to earth or phase-to-
phase voltages, positive and negative
sequence voltages and the residual voltage.
In addition, the IED monitors active, reactive
and apparent power, the power factor, power
demand value over a user-selectable pre-set
time frame as well as cumulative active and
reactive energy of both directions. Line
frequency, the calculated temperature of the
feeder, and the phase unbalance value based
on the ratio between the negative sequence
and positive sequence current are also
calculated. Cumulative and averaging
calculations utilize the non-volatile memory
available in the IED.
The values measured are accessed locally via
the front-panel user interface of the IED or
remotely via the communication interface of
the IED. The values are also accessed locally
or remotely using the web-browser based
user interface.
8. Disturbance recorder
The IED is provided with a disturbance
recorder featuring up to 40 analog and 64
binary signal channels. The analog channels
can be set to record the waveform of the
currents and voltage measured. The analog
channels can be set to trigger the recording
when the measured value falls below or
exceeds the set values. The binary signal
channels can be set to start a recording on
the rising or the falling edge of the binary
signal. The binary channels are set to record
external or internal IED signals, for example
the start or operate signals of the protection
functions, or external blocking or control
signals. Binary IED signals such as a
protection start or trip signal, or an external
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IED control signal over a binary input can be
set to trigger the recording. In addition, the
disturbance recorder settings include pre and
post triggering times.
The disturbance recorder can store up to 100
recordings. The number of recordings may
vary depending on the length of the
recording and the number of signals
included. The disturbance recorder controls
the Start and Trip LEDs on the front-panel
user interface. The operation of the LEDs is
fully configurable enabling activation when
one or several criteria, i.e. protection function
starting or tripping, are fulfilled.
The recorded information is stored in a non-
volatile memory and can be uploaded for
subsequent fault analysis.
9. Event log
The IED features an event log which enables
logging of event information. The event log
can be configured to log information
according to user pre-defined criteria
including IED signals. To collect sequence-of-
events (SoE) information, the IED
incorporates a non-volatile memory with a
capacity of storing 1000 events with
associated time stamps and user definable
event texts. The non-volatile memory retains
its data also in case the IED temporarily loses
its auxiliary supply. The event log facilitates
detailed pre- and post-fault analyses of faults
and disturbances.
The SoE information can be accessed locally
via the user interface on the IED front panel
or remotely via the communication interface
of the IED. The information can further be
accessed, either locally or remotely, using the
web-browser based user interface.
The logging of communication events is
determined by the used communication
protocol and the communication engineering.
The communication events are automatically
sent to station automation and SCADA
systems once the required communication
engineering has been done.
10. Disturbance report
The disturbance report includes information
collected during the fault situation. The
report includes general information such as
recording time, pre-fault time and post fault
time. Further, the report includes pre-fault
magnitude, pre-fault angle, fault magnitude
and fault angle trip values. By default, the
disturbance reports are stored in a non-
volatile memory. The numerical disturbance
report can be accessed via the local front
panel user interface. A more comprehensive
disturbance report with waveforms is
available using PCM600.
11. Circuit-breaker
monitoring
The condition monitoring functions of the
IED constantly monitors the performance and
the condition of the circuit breaker. The
monitoring comprises the spring charging
time, SF6 gas pressure, the travel-time and
the inactivity time of the circuit breaker.
The monitoring functions provide operational
CB history data, which can be used for
scheduling preventive CB maintenance.
12. Trip-circuit
supervision
The trip-circuit supervision continuously
monitors the availability and operability of
the trip circuit. It provides open-circuit
monitoring both when the circuit breaker is
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in its closed and in its open position. It also
detects loss of circuit-breaker control voltage.
13. Self-supervision
The IED’s built-in self-supervision system
continuously monitors the state of the IED
hardware and the operation of the IED
software. Any fault or malfunction detected
will be used for alerting the operator.
Self-supervision events are saved into an
internal event list which can be accessed
locally via the user interface on the IED front
panel. The event list can also be accessed
using the web-browser based user interface
or PCM600.
14. Fuse failure
supervision
The fuse failure supervision detects failures
between the voltage measurement circuit and
the IED. The failures are detected by the
negative-sequence based algorithm or by the
delta voltage and delta current algorithm.
Upon the detection of a failure the fuse
failure supervision function activates an alarm
and blocks voltage-dependent protection
functions from unintended operation.
15. Current circuit
supervision
Current circuit supervision is used for
detecting faults in the current transformer
secondary circuits. On detecting of a fault the
current circuit supervision function can also
activate an alarm LED and block certain
protection functions to avoid unintended
operation. The current circuit supervision
function calculates the sum of the phase
currents and compares the sum with the
measured single reference current from a
core balance current transformer or from
another set of phase current transformers.
16. Access control
To protect the IED from unauthorized access
and to maintain information integrity the IED
is provided with an authentication system
including user management. Using the IED
user management tool in the Protection and
Control IED Manager PCM600, an individual
password is assigned to each user by the
administrator. Further, the user name is
associated to one or more of the four
available user groups: System Operator,
Protection Engineer, Design Engineer and
User Administrator. The user group
association for each individual user enables
the use of the IED according to the profile of
the user group.
17. Inputs and outputs
Depending on the hardware configuration
selected, the IED is equipped with three phase-
current inputs and one or two residual-
current inputs for earth-fault protection. The
IED always includes one residual voltage
input for directional earth-fault protection or
residual voltage protection. Further, the IED
includes three phase-voltage inputs for
overvoltage, undervoltage and directional
overcurrent protection and other voltage
based protection functions. Depending on the
hardware configuration, the IED also includes
a dedicated voltage input for synchrocheck.
The phase-current inputs are rated 1/5 A. The
IED is equipped with one or two alternative
residual-current inputs, that is 1/5 A or
0.1/0.5 A. The 0.1/0.5 A input is normally
used in applications requiring sensitive earth-
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fault protection and featuring a core-balance
current transformer.
The three phase-voltage inputs, for either
phase-to-phase voltages or phase-to-earth
voltages, and the residual-voltage input cover
the rated voltages 100 V, 110 V, 115 V and
120 V. The rated values of the current and
voltage inputs are selected in the IED software.
In addition, the binary input thresholds are
selected by adjusting the IED’s parameter
settings. The threshold voltage can be set
separately for each binary input.
All binary input and output contacts are
freely configurable using the signal matrix of
the application condiguration function in
PCM600.
Please refer to the Input/output overview
tables, the selection and ordering data and
the terminal diagrams for more detailed
information about the inputs and outputs.
Table 3. Analog input options
Analog input
configuration
CT (1/5 A) CT sensitive
(0.1/0.5 A)
VT
AA 4 - 5
AB 4 1 4
AC 3 1 5
Table 4. Binary input/output options
Binary input options
BI BO
Default 14 9
With one optional binary I/O
module
23 18
With two optional binary I/O
modules
32 27
18. Communication
The IED supports the new IEC 61850
substation automation standard including
horizontal GOOSE communication as well as
the well-established DNP3 (TCP/IP) protocol.
All operational information and controls are
available through these protocols.
Disturbance files are accessed using the IEC
61850 protocol. Disturbance files are
available to any Ethernet based application in
the standard COMTRADE format. Further, the
IED sends and receives binary signals from
other IEDs using the IEC 61850-8-1 GOOSE
profile. The IED meets the GOOSE
performance requirements for tripping
applications in distribution substations, as
defined by the IEC 61850 standard. The IED
interoperates with other IEC 61850 compliant
IEDs, tools and systems and simultaneously
reports events to five different clients on the
IEC 61850 station bus. For a system using
DNP3 over TCP/IP, events can be sent to four
different masters.
All communication connectors, except for the
front port connector, are placed on integrated
communication modules. The IED is
connected to Ethernet-based communication
systems via the RJ-45 connector (10/100BASE-
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TX) or the fibre-optic multimode LC
connector (100BASE-FX).
The IED supports SNTP, DNP3 and IRIG-B
time synchronization methods with a time-
stamping resolution of 1 ms.
Ethernet based:
SNTP (Simple Network Time Protocol)
DNP3
With special time synchronization wiring:
IRIG-B (Inter-Range Instrumentation Group
- Time Code Format B)
Table 5. Supported communication interface and protocol alternatives
Interfaces/Protocols
1)
Ethernet
100BASE-TX RJ-45
Ethernet
100BASE-FX LC
IEC 61850
DNP3
= Supported
1) Please refer to the Selection and ordering data chapter for more information
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19. Technical data
Table 6. Dimensions
Description Type Value
Width half 19" 220 mm
Height half 19" 177 mm (4U)
Depth half 19" 249.5 mm
Weight half 19" box 6.2 kg (4U)
half 19" LHMI 1.0 kg (4U)
Table 7. Power supply
Description
Type 1 Type 2
U
aux
nominal 100, 110, 120, 220, 240 V
AC, 50 and 60 Hz
48, 60, 110, 125 V DC
110, 125, 220, 250 V DC
U
aux
variation 85...110% of U
n
(85...264 V
AC)
80...120% of U
n
(38.4...150 V
DC)
80...120% of U
n
(88...300 V
DC)
Maximum load of auxiliary
voltage supply
35 W
Ripple in the DC auxiliary
voltage
Max 15% of the DC value (at frequency of 100 Hz)
Maximum interruption time in
the auxiliary DC voltage
without resetting the IED
50 ms at U
aux
Power supply input must be
protected by an external
miniature circuit breaker
For example, type S282 UC-K
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Table 8. Energizing inputs
Description Value
Rated frequency 50/60 Hz
Operating range Rated frequency ± 5 Hz
Current inputs Rated current, I
n
0.1/0.5 A
1)
1/5 A
2)
Thermal withstand
capability:
Continuously 4 A 20 A
For 1 s 100 A 500 A
For 10 s 20 A 100 A
Dynamic current
withstand:
Half-wave value 250 A 1250 A
Input impedance <100 mΩ <20 mΩ
Voltage inputs Rated voltage 100 V/ 110 V/ 115 V/ 120 V (Parametrization)
Voltage withstand:
Continuous 425 V
For 10 s 450 V
Burden at rated voltage <0.05 VA
1) Residual current
2) Phase currents or residual current
Table 9. Binary inputs
Description
Value
Operating range Maximum input voltage 300 V DC
Rated voltage 24...250 V DC
Current drain 1.6...1.8 mA
Power consumption/input <0.3 W
Threshold voltage 15...221 V DC (parametrizable in the range in
steps of 1% of the rated voltage)
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Table 10. Signal output and IRF output
IRF relay change over - type signal output relay
Description Value
Rated voltage 250 V AC/DC
Continuous contact carry 5 A
Make and carry for 3.0 s 10 A
Make and carry 0.5 s 15 A
Breaking capacity when the control-circuit
time constant L/R<40 ms, at U< 48/110/220
V DC
≤0.5 A/≤0.1 A/≤0.04 A
Minimum contact load 100 mA at 24 V AC/DC
Table 11. Power output relays, with or without TCS function
Description
Value
Rated voltage 250 V AC/DC
Continuous contact carry 8 A
Make and carry for 3.0 s 15 A
Make and carry for 0.5 s 30 A
Breaking capacity when the control-circuit
time constant L/R<40 ms, at U< 48/110/220
V DC
≤1 A/≤0.3 A/≤0.1 A
Minimum contact load 100 mA at 24 V AC/DC
Table 12. Power output relays with TCS function
Description
Value
Control voltage range 20...250 V DC
Current drain through the supervision circuit ~1.0 mA
Minimum voltage over the TCS contact 20 V DC
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Table 13. Ethernet interfaces
Ethernet interface Protocol Cable Data transfer rate
LAN/HMI port (X0)
1)
- CAT 6 S/FTP or better 100 MBits/s
LAN1 (X1) TCP/IP protocol Shielded twisted pair
CAT 5e cable with
RJ-45 connector or
fibre-optic cable with
LC connector
100 MBits/s
1) Only available for the external HMI option.
Table 14. Fibre-optic communication link
Wave length
Fibre type Connector Permitted path
attenuation
1)
Distance
1300 nm MM 62.5/125
μm glass
fibre core
LC <8 dB 2 km
1) Maximum allowed attenuation caused by connectors and cable together
Table 15. X4/IRIG-B interface
Type
Protocol Cable
Screw terminal, pin
row header
IRIG-B Shielded twisted pair cable
Recommended: CAT 5, Belden RS-485 (9841-
9844) or Alpha Wire (Alpha 6222-6230)
Table 16. Serial rear interface
Type
Counter connector
1)
Serial port (X9) Optical ST connector or optical snap-in
connector
1) For future use
Table 17. Degree of protection of flush-mounted IED
Description
Value
Front side IP 40
Rear side, connection terminals IP 20
Table 18. Degree of protection of the LHMI
Description
Value
Front and side IP 42
Feeder Protection and Control 1MRS756380 A
REF630
Product version: 1.0 Issued: 15.09.2009
20 ABB
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ABB REF630 User manual

Type
User manual

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